Effect of fines migration and mineral reactions on CO2-water drainage relative permeability

Ge, Jiachao; Zhang, Xiaozhou; Othman, Faisal; Wang, Yamin; Roshan, Hamid; Le-Hussain, Furqan

doi:10.1016/j.ijggc.2020.103184

Cited by 23 publications

(6 citation statements)

References 57 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Based on these observations, we come to the conclusion that an additional mechanismnamely, mechanical mobilization of the solid phaseis occurring along the fracture face during the acid floods. Dissolution-induced fines migration has been observed in conventional rocks, ,− where the carbonaceous cement holding the grains in place is dissolved during acidization and/or CO 2 injection resulting in fines mobilization. The mobilized fines move deeper inside the rock/fracture with flow and are “strained” at narrow pore throats or fracture constrictions.…”

Section: Discussionmentioning

confidence: 99%

Impact of Concurrent Solubilization and Fines Migration on Fracture Aperture Growth in Shales during Acidized Brine Injection

2022

View full text Add to dashboard Cite

Acidic hydraulic fracturing fluid chemically and physically alters shale rock fabric during injection and shut-in, creating a “reaction-altered zone” along the fracture faces. To better characterize the variable thickness and composition of this reaction-altered zone under advective flow, we take a coupled experimental and modeling approach. A fluidic cell, with six fiducial markers, is first fabricated to keep the rock sample in place during the core floods and to allow image alignment of acquired images. Then, we conduct a series of reactive core floods in a clay-rich siliceous Wolfcamp shale sample with 10 wt % carbonate, using a synthetic fracturing fluid under no confining stress and at room temperature. High-resolution computed tomography (CT) scans are periodically conducted to observe the spatial alteration of the fracture network. We then perform scanning electron microscopy (SEM-EDS) on the two orthogonal surfaces (fracture surface and freshly cut profile face) to generate high-resolution elemental maps that show the change in mineralogy, both with distance along a given flow path along a fracture surface and with depth from the fracture surface into the shale matrix. These results are contrasted against a two-dimensional (2D) advection-diffusion reaction model developed previously for batch reactions between shale and synthetic fracturing fluids. The model simulates the geochemical interaction occurring at the fracture/matrix interface and penetrating into the shale matrix during the reactive core flood. Both model and experimental results show that the acidic brine is neutralized during the core flood, corresponding to an increase in fracture aperture as a function of fluid volume injected with the greatest change near the inlet. SEM-EDS scans reveal significant dissolution of carbonates on the fracture surface without pyrite oxidation. The reactive transport model indicates that carbonate depletion into the shale interior should be observable, yet SEM-EDS shows no discernible loss of carbonate in the orthogonal profile face. The combination of these observations suggests an additional fracture evolution mechanism in the reactive system, i.e., fines migration. We show that fines migration enhances the access of fracturing fluid to the matrix resulting in a more pronounced fracture widening. We conclude that coupled mineral dissolution and fines migration govern fracture aperture growth during acidized brine injection. In this work, we effectively show the underlying risk of relying solely on models that do not include an important (transport) process that can alter the system significantly and propose a combined chemomechanical mechanism for fracture evolution appropriate for this shale mineralogy.

show abstract

Section: Discussionmentioning

confidence: 99%

Impact of Concurrent Solubilization and Fines Migration on Fracture Aperture Growth in Shales during Acidized Brine Injection

2022

View full text Add to dashboard Cite

show abstract

“…Ge et al. (2020) and Zhang et al. (2020) suggest that a primary impact of fines migration is the mobilization of fines and subsequent blockage of pore throats, leading to reduced permeability.…”

Section: Introductionmentioning

confidence: 99%

“…Evidence of fines migration has been observed in Berea sandstones as a result of core flooding with scCO 2 -saturated brine (Ge et al, 2020;Othman et al, 2019); a companion study (Zhang et al, 2020) indicated that the mineral phases kaolinite, chlorite, and muscovite exhibited physical and/or chemical changes after exposure to scCO 2 -saturated brine and were most likely to be mobilized (in contrast to quartz and microcline, a potassium-rich feldspar, which showed no changes upon exposure). Ge et al (2020) and Zhang et al (2020) suggest that a primary impact of fines migration is the mobilization of fines and subsequent blockage of pore throats, leading to reduced permeability. In a more recent study, Ge et al (2022) also found that fines migration increased residual saturation of scCO 2 ; the authors attribute this effect also to pore throat blockage.…”

mentioning

confidence: 99%

Evolution of Bentheimer Sandstone Wettability During Cyclic scCO₂‐Brine Injections

Herring

Sun

Armstrong

et al. 2021

Water Resources Research

View full text Add to dashboard Cite

Almost all scenarios that limit climate-change-caused temperature rise to ≤2°C rely on large-scale geologic sequestration to redirect carbon dioxide (CO 2 ) emissions away from the atmosphere and instead into underground storage (IPCC, 2014(IPCC, , 2019. Geologic sequestration is being considered both as a way to prevent carbon emissions from large point source polluters (e.g., fossil fuel energy production, cement manufacturers), and also as a potential negative emissions technology when coupled with bioenergy with carbon capture and storage, or direct air capture (Bui et al., 2018;IEA, 2020;IPCC, 2005IPCC, , 2019. The short-term (i.e., order of decades) security of a geologic sequestration operation in a sedimentary formation relies on two physical mechanisms: (a) the presence of a sound impermeable caprock to enable "structural" trapping of the relatively buoyant CO 2 plume below the caprock (Shukla et al., 2010; Song & Zhang, 2013), and (b) the interfacial interactions between rock-CO 2 -resident brine which break off small bubbles of disconnected CO 2 within the pore structure of the rock formation, termed "capillary" or "residual" trapping (Abidoye

show abstract

“…Previous studies on the influence of the micropore structure of tight sandstone gas reservoirs have mainly focused on the electrical properties and permeability of rocks. Compared with these two aspects, the relative permeability of gas–water can reflect the gas–water migration law and residual gas distribution state in real micropore structures. − The results showed that the relative permeability, water saturation, and residual gas–water distribution are closer to real gas well production. Ma et al established a calculation model for calculating the relative permeability of gas and water phases from the resistivity index based on the Poiseuille formula and Darcy law.…”

Section: Introductionmentioning

confidence: 97%

Research on the Relationship between Electrical Parameters and Relative Permeability of Tight Sandstone

Zhao

Song

et al. 2022

ACS Omega

View full text Add to dashboard Cite

The relationship between the electrical properties and relative permeability of tight sandstones with complex pore-throat structures is still unclear. In this study, a relationship model between the electrical parameters and pore-throat structure and the relative permeability of tight sandstone based on experimental data was established by combining theoretical derivation and experimental comparison. The model has typical three-terminal element characteristics. Porosity had little effect on relative permeability, whereas saturation index had a significant control effect on relative permeability. The relative permeability curve deduced based on the electrical parameters was quite different from the experimental fitting curve. Because irreducible water could conduct electricity but not flow, the relative permeability of the gas phase derived from the theory was higher than the experimental one, while the relative permeability of the water phase was lower. The isotonic point saturation of the phase permeability curve derived from the rock electrical parameter theory was larger than that obtained from the experiment. This research could help us obtain accurate relative permeability curves through electrical parameters and provide a basis for the fine evaluation of tight sandstone two-phase flow.

show abstract

Effect of fines migration and mineral reactions on CO2-water drainage relative permeability

Cited by 23 publications

References 57 publications

Impact of Concurrent Solubilization and Fines Migration on Fracture Aperture Growth in Shales during Acidized Brine Injection

Impact of Concurrent Solubilization and Fines Migration on Fracture Aperture Growth in Shales during Acidized Brine Injection

Evolution of Bentheimer Sandstone Wettability During Cyclic scCO₂‐Brine Injections

Research on the Relationship between Electrical Parameters and Relative Permeability of Tight Sandstone

Contact Info

Product

Resources

About

Effect of fines migration and mineral reactions on CO2-water drainage relative permeability

Cited by 23 publications

References 57 publications

Impact of Concurrent Solubilization and Fines Migration on Fracture Aperture Growth in Shales during Acidized Brine Injection

Impact of Concurrent Solubilization and Fines Migration on Fracture Aperture Growth in Shales during Acidized Brine Injection

Evolution of Bentheimer Sandstone Wettability During Cyclic scCO2‐Brine Injections

Research on the Relationship between Electrical Parameters and Relative Permeability of Tight Sandstone

Contact Info

Product

Resources

About

Evolution of Bentheimer Sandstone Wettability During Cyclic scCO₂‐Brine Injections